Monitoring hydrocarbon reservoirs using induced polarization effect

ABSTRACT

Some examples of monitoring hydrocarbon reservoirs using induced polarization effect includes inducing polarization in a subterranean zone using an induced polarization fluid. The subterranean zone includes first formations and second formations. A quantity of hydrocarbons in the first formations is greater than quantity of hydrocarbons in the second formations. The induced polarization data is obtained from the subterranean zone. A portion of the induced polarization data from the first formations is different from a portion of the induced polarization data from the second formations. The second formations in the subterranean zone are identified based on the obtained induced polarization data

TECHNICAL FIELD

This application relates to hydrocarbon reservoir monitoring orhydrocarbon reservoir imaging (or both).

BACKGROUND

Electromagnetic (EM) surveys are widely used in geophysical explorationand other applications. These surveys are based on measurements of theelectric or magnetic fields (or both) on the ground, in boreholes, atthe sea bottom or from airborne platforms. Compared to traditionalseismic technology, EM technology is a more reliable and directindicator of subsurface hydrocarbons. EM technology can be complementaryto traditional seismic technology and can raise exploration successrates. EM methods can be extended to the production phase through thedevelopment of integrated four-dimensional EM dataacquisition/interpretation method for the monitoring of producing wellsin connection with the enhanced recovery of hydrocarbons (“EOR”) andenvironmental monitoring of carbon dioxide deposits in geologicalformations.

SUMMARY

This application relates to monitoring hydrocarbon reservoirs usinginduced polarization effect.

In some aspects, a method includes inducing polarization in asubterranean zone using an induced polarization fluid. The subterraneanzone includes first formations and second formations. A quantity ofhydrocarbons in the first formations is greater than quantity ofhydrocarbons in the second formations. The induced polarization data isobtained from the subterranean zone. A portion of the inducedpolarization data from the first formations is different from a portionof the induced polarization data from the second formations. The secondformations in the subterranean zone are identified based on the obtainedinduced polarization data.

This, and other aspects, can include one or more of the followingfeatures. The induced polarization fluid can be flowed into thesubterranean zone. The second formations can absorb more inducedpolarization fluid than the first formations. The induced polarizationfluid can include an injection fluid that can include multiple particlesconfigured to induce polarization in an electromagnetic field. Themultiple particles can include nanoparticles. The injection fluid caninclude organic material. The multiple particles can include inorganicmaterial. The injection fluid can include brine. The subterranean zonecan include an injection wellbore into which the induced polarizationfluid can be flowed. Flow of the induced polarization fluid through theinjection wellbore can be traced based, in part, on the obtained inducedpolarization data. The first formations can include reservoir rock atleast partially saturated with hydrocarbons. To induce polarization inthe subterranean zone using the induced polarization fluid, an inducedpolarization system can be positioned in the subterranean zone. Theinduced polarization system can include a transmitter positioned withinthe subterranean zone and multiple receivers, each positioned on asurface of the subterranean zone. The transmitter can be configured totransmit an electromagnetic signal through the subterranean zone. Theinduced polarization data can be generated in the subterranean zone inresponse to the electromagnetic signal. Each receiver can be configuredto measure at least a portion of the induced polarization data generatedin the subterranean zone in response to the electromagnetic signal. Toidentify second formations based on the obtained induced polarizationdata, volume distribution of electrical resistivity and chargeability inthe subterranean zone from the induced polarization data can bedetermined. To determine the volume distribution of electricalresistivity and chargeability in the subterranean zone, athree-dimensional electromagnetic inversion technique can be applied onthe obtained induced polarization data. Changes to the electricalresistivity and chargeability in the subterranean zone can be monitored.The changes to the electrical resistivity and chargeability can becorrelated to rock formations in the subterranean zone. Changes toelectrical resistivity and chargeability in the first formations can bedifferent from changes to electrical resistivity and chargeability inthe second formations that have absorbed the induced polarization fluid.Correlating the changes to the electrical resistivity and chargeabilityto rock formations in the subterranean zone can include differentiatingbetween first formations and second formations based on differencesbetween the changes to the electrical resistivity and chargeability inthe first formations and the changes to the electrical resistivity andchargeability in the second formations that have absorbed the inducedpolarization fluid.

In some aspects, a system includes processing circuitry configured toperform operations. The operations include obtaining inducedpolarization data from a subterranean zone. The subterranean zoneincludes first formations and second formations. A quantity ofhydrocarbons in the first formations is greater than quantity ofhydrocarbons in the second formations. The induced polarization data isobtained from the subterranean zone. A portion of the inducedpolarization data from the first formations is different from a portionof the induced polarization data from the second formations. Theoperations include identifying the second formations in the subterraneanzone based on the obtained induced polarization data.

This, and other aspects, can include one or more of the followingfeatures. A transmitter can be positioned within the subterranean zone.Multiple receivers can be positioned on a surface of the subterraneanzone. The transmitter can be configured to transmit an electromagneticsignal through the subterranean zone. The induced polarization data canbe generated in the subterranean zone in response to the electromagneticsignal. Each receiver can be configured to measure at least a portion ofthe induced polarization data generated in the subterranean zone inresponse to the electromagnetic signal. The system can include aninduced polarization fluid including multiple particles configured toinduced polarization in an electromagnetic field. The multiple particlescan include nanoparticles. The injection fluid can include organicmaterial. The multiple particles can include inorganic material. Theinjection fluid can include brine. The subterranean zone can include aninjection wellbore into which the induced polarization fluid can beflowed. The processing circuitry can further be configured to trace flowof the induced polarization fluid through the injection wellbore based,in part, on the obtained induced polarization data. The system caninclude a pumping system configured to flow the induced polarizationfluid into the subterranean zone. To identify the second formationsbased on the obtained induced polarization data, the processingcircuitry can be configured to determine volume distribution ofelectrical resistivity and chargeability in the subterranean zone fromthe induced polarization data. To determine volume distribution ofelectrical resistivity and chargeability in the subterranean zone fromthe induced polarization data, the processing circuitry can beconfigured to apply a three-dimensional electromagnetic inversiontechnique on the obtained induced polarization data. The processingcircuitry can be configured to monitor changes to the electricalresistivity and chargeability in the subterranean zone and correlate thechanges to the electrical resistivity and chargeability to rockformations in the subterranean zone. The changes to the electricalresistivity and chargeability can be correlated to rock formations inthe subterranean zone. Changes to electrical resistivity andchargeability in the first formations can be different from changes toelectrical resistivity and chargeability in the second formations thathave absorbed the induced polarization fluid. To correlate the changesto the electrical resistivity and chargeability to rock formations inthe subterranean zone, the processing circuitry can be configured todifferentiate between first formations and second formations based ondifferences between the changes to the electrical resistivity andchargeability in the first formations and the changes to the electricalresistivity and chargeability in the second formations that haveabsorbed the induced polarization fluid.

The details of one or more implementations of the subject matterdescribed in this specification are set forth in the accompanyingdrawings and the description below. Other features, aspects, andadvantages of the subject matter will become apparent from thedescription, the drawings, and the claims.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a schematic diagram of an example of a subterranean zoneincluding an induced polarization system.

FIGS. 2A and 2B show example of complex resistivity spectra of anexample rock that has absorbed induced polarization fluid.

FIG. 2C shows an example of complex resistivity spectra determined for aportion of a subterranean zone.

FIG. 3 is a flowchart of an example of a process for monitoring asubterranean zone using induced polarization.

DETAILED DESCRIPTION

EM technology can be used to monitor hydrocarbon reservoirs by combinedsurface and wellbore resistivity mapping. One technique to monitorhydrocarbon reservoirs based on resistivity is to inject tracer fluidinto the reservoir. The tracer fluid has a resistivity that is differentfrom a resistivity of the reservoir into which the fluid is injected.Such monitoring techniques are limited because fluids injected during adrilling process can have high conductivity and adding conductiveparticles may provide insignificant effect on the observed EM data.

This application describes monitoring hydrocarbon reservoirs usinginduced polarization effect. In some implementations, a reservoir tracerfluid (or fluids) (referred to as an induced polarization fluid in thisapplication) filled with nanoparticles is injected into a subterraneanzone. The subterranean zone can include a formation, a portion of aformation or multiple formations. As described below, the tracer fluidfilled with nanoparticles can generate induced polarization (IP) effectsin reservoir rocks in the subterranean zone. The IP effects in reservoirrocks containing hydrocarbons (for example, oil, gas, other hydrocarbonsor combinations of them) can be different from the IP effects inreservoir rocks containing comparatively lesser hydrocarbons. Usingelectromagnetic methods described here, the IP response from thesubterranean zone can be measured and used to map the subterranean zoneor monitor the movement of the injected fluids in the subterranean zone(or both). In particular, flowing nanoparticles in a carrier fluidthrough the reservoir can increase the contrast in IP response betweenhydrocarbon-rich portions and comparatively hydrocarbon-poor portions ofthe formation. In addition, including the nanoparticles in the carrierfluid can increase the contrast in IP response that is obtained usingthe carrier fluid alone.

Mapping the subterranean zone or monitoring the movement of injectedfluids in the subterranean zone (or both) can increase hydrocarbonrecovery from the subterranean zone. The techniques described here canalso be implemented to optimize the placement of wellbores in thesubterranean zone. Ultimately mapping hydrocarbons accumulations in theinter-well volumes allow to identify bypassed reserves and maximize thehydrocarbon recovery.

FIG. 1 is a schematic diagram of an example of a subterranean zone 104including an IP system 150. The subterranean zone 104 can include aformation 105 a, multiple formations (for example, a first formation 105a, a second formation 105 b, or other formations), or a portion of aformation. The subterranean zone 104 can include a geographical area tobe drilled or being drilled for hydrocarbons or that has been drilledand from which hydrocarbons are to be produced or are being produced. Insome implementations, a wellbore 112 can have been drilled in thesubterranean zone 104. All or portions of the wellbore 112 can have beencased with a casing 114. For example, the wellb ore 112 can be aproduction wellbore or an injection wellbore into which injection fluidis to be injected for secondary or tertiary production in an adjacentproduction wellbore (not shown). In some implementations, the techniquesdescribed here can be implemented without a wellbore.

In some implementations, the IP system 150 can be a sub-surface tosurface system configured to measure spectral IP effects in thereservoir rocks. The IP system 150 can include a transmitter systempositioned sub-surface, i.e., below a surface 102 and within thesubterranean zone 104. In some implementations, the transmitter systemcan include a transmitting bipole that includes two electrode points—afirst electrode 109 a serving as a surface grounding point and a secondelectrode 109 b grounded inside the casing 114 (or grounded at somedepth inside the subterranean zone 104). The IP system 150 can alsoinclude multiple receivers (for example, a first receiver 110 a, asecond receiver 110 b, a third receiver 110 c, a fourth receiver 110 d,a fifth receiver 110 e, and more or fewer receivers) positioned on thesurface 102. In some implementations, the multiple receivers can bedistributed at different locations on the surface 102 to form atwo-dimensional array. For example, the multiple receivers can bedistributed on the surface 102 such that the entrance to the wellbore112 is at a center of the array. In some implementations, thetransmitters 109 a and 109 b can be positioned inside multiplewellbores. In some implementations, the array of receivers can bepositioned in the subterranean zone 104 (i.e., below the surface 102).

In some implementations, a pumping system 106 can pump an IP fluid 125into the subterranean zone 104. The IP fluid 125 can include any fluidthat includes organic material. The IP fluid 125 can be aqueous fluid(such as water) with variable salts. For example, the fluid can includebrine. In some implementations, the fluid can be injection fluid to beflowed into an injection wellbore. The fluid can be doped with multipleparticles, for example, nanoparticles or particles having a range ofsizes (such as a mixture of nanometer and micrometer-sized particles).The particles can include inorganic materials. For example, theparticles can include ferrous material or other material in whichpolarization can exhibit polarization in an electromagnetic field.Doping the fluid with the multiple particles can result in an IP fluidin which polarization can be induced in an electromagnetic field.Examples of particles that can be used include Fe₃O₄, Fe₂O₃, NiO, Al₂O₃in nanoparticle form or any other nanoparticle capable of an inducedpolarization effect (that is, chargeability) under a frequency variableelectromagnetic field.

The subterranean zone 104 can include some portions that carry higherquantities of hydrocarbons (for example, oil, gas or other hydrocarbons)compared to other portions. For example, some portions can besubstantially saturated with hydrocarbons while others can besubstantially free of hydrocarbons. The quantity of the IP fluid 125that is absorbed by the portions that carry higher quantities ofhydrocarbons can be less than the quantity of the IP fluid 125 that isabsorbed by the portions that carry lower quantities of hydrocarbons.The IP system 150 can include processing circuitry 152 configured toimage the subterranean zone 104 based on the IP data output by the IPfluid 125, as described below. Such imaging can distinguish portions ofthe subterranean zone that carry more hydrocarbons from portions thatcarry comparatively fewer hydrocarbons.

In operation, the pumping system 106 can be operated to flow the IPfluid 125 into the subterranean zone 104. In some implementations, theIP fluid 125 can be injected in the subterranean zone 104 throughinjector wellbores. A quantity of the IP fluid 125 flowed into thesubterranean zone 125 can be sufficient to occupy a significant fractionof the porous space in the reservoir so that an induced polarizationvariation can be measured in the area of interest. A significantfraction of the porous space in the reservoir can include, for example,greater than 30% of the porous space, between 40% and 90% of the porousspace, between 50% and 80% of the porous space, between 60% and 70% ofthe porous space, to name a few ranges. The processing circuitry 152 inthe IP system 150 can be connected to the transmitter system and themultiple receivers. The processing circuitry 152 can cause thetransmitter system to transmit an electromagnetic signal through thesubterranean zone 104. The electromagnetic signal can be sinusoidal andhave a frequency range selected from 0.01 Hz (Hertz) to 1 kHz (kiloHertz). The amplitude of the sinusoidal waveform can be chosen toprovide a high signal-to-noise ratio from 200 mV (milli volt) to 10volts. The responses from portions of the subterranean zone 104 can becompared with corresponding responses from a reference, for example,reference resistors. For each pair of responses, the difference in phaseand amplitude between the two sinusoidal waveforms can be recorded andstored for each current frequency. The differences can be converted intothe pairs of real and imaginary parts of complex resistivity for eachfrequency. When collated, these individual complex resistivitymeasurements form the complex resistivity spectra. In response, the IPfluid 125 flowed through the subterranean zone 104 can output IP data.

The multiple receivers can record either the frequency domain or timedomain EM field and the corresponding spectral IP effect associated withthe IP fluid 125 penetrating the different portions of the subterraneanzone 104. The multiple receivers can transmit the recorded EM field tothe processing circuitry 152. FIGS. 2A and 2B show example of complexresistivity spectra of an example rock that has absorbed IP fluid 125.The spectra show a dependence of the complex resistivity of amount(volume percent) of ferrous nanoparticles doped in partly saturated (10%v/v) by saltwater sand cartridges. FIG. 2A shows the plots of the realpart of the complex resistivity spectrum for different volumepercentages of inorganic ferrous nanoparticles doped in the salt water.FIG. 2B shows the imaginary part of the same complex resistivityspectrum of ferrous nanoparticles doped in partly (10% v/v) saturated bysaltwater sand cartridges.

Using the obtained spectral induced potential data received from themultiple receivers, the processing circuitry 152 can determine volumeimages of the electrical resistivity and chargeability of thesubterranean zone 104. To do so, in some implementations, the processingcircuitry 152 can implement a three-dimensional electromagneticinversion technique to the obtained induced potential data.

The induced potential phenomenon can be mathematically explained by acomposite geoelectrical model of the subterranean zone 104. The model isbased on the effective-medium approach, which takes into account boththe volume polarization and the surface polarization of the porousspace. The composite geoelectrical model can allow modeling therelationships between the physical characteristics of different types ofrocks and minerals (for example, conductivities, porosity,polarizability) and the parameters of the relaxation model. Ageneralized effective-medium theory of the induced polarization (GEMTIP)treats in a unified way different complex multiphase composite models ofthe rocks. In some implementations, the processing circuitry 152 canimplement the GEMTIP model consisting of a medium filled with randomlyoriented ellipsoidal inclusions. The ellipsoidal inclusions can be usedto describe a variety of different shapes ranging from prolateellipsoids, approximating thin laminating layers, to the oblaterelatively thin ellipsoids approximating thin capillaries in the porousspace. The GEMTIP model parameters can include the DC resistivity, ρ₀,the chargeability parameter, the time constant, and the decay constantof the complex resistivity curves. The chargeability term is a linearfunction of the fraction volume of the inclusions, and therefore can beexpressed as a linear function of the porosity.

Using the three-dimensional electromagnetic inversion technique of theinduced potential data acquired over the subterranean zone 104, theprocessing circuitry 152 can recover a three-dimensional porosity modelfrom a transform of the three-dimensional chargeability model. Theprocessing circuitry 152 can determine three-dimensional fluidsaturation models by interpreting the transformation of thethree-dimensional chargeability model simultaneously with thethree-dimensional resistivity model.

According to the GEMTIP approach, the effective resistivity model for amedium with randomly oriented ellipsoidal inclusions is given by thefollowing equation.

$\rho_{e} = {\rho_{0}\left\{ {1 + {\frac{p}{9}{\sum\limits_{{\alpha = x},y,z}^{\;}{\frac{1}{\gamma_{\alpha}}\left\lbrack {1 - \frac{1}{1 + {s_{\alpha}\left( {i\; \omega \; \tau} \right)}^{c}}} \right\rbrack}}}} \right\}}$

In the above equation, ρ₀ is DC resistivity, ω is frequency, p ischargeability parameter, τ is time constant, and C is relaxationparameter. The coefficients γ_(α) and s_(α) (α=x, y, z) are thestructural parameters defined by geometrical characteristics of theellipsoidal inclusions used to approximate the porous space. A vector ofthe unknown model parameters is introduced.

m=[p,τ,C,γ,s]

A vector, d, of the observed data (i.e., the values of complexresistivity as function of frequency):

d=[ρ _(e)(ω₁),ρ_(e)(ω₂), . . . ρ_(e)(ω_(n))].

Using these notations, the equation above can be written in thefollowing form:

d=A(m).

To find the parameters of the GEMTIP model, the equation above can besolved with respect to m. To do so, the processing circuitry 152 canimplement an inversion algorithm based on the regularized conjugategradient (RCG) method, which is an iterative solver that updates themodel parameters on each iteration using conjugate gradient directions({tilde over (l)}^(α)) according to the following formula:

m _(n+1) =m _(n) +δm _(n) =m _(n) −k _(n) {tilde over (l)} ^(α)(m _(n))

In the equation above, k_(n) denotes the iteration steps. Experimentalresults comparing the observed and GEMTIP predicted data for a rocksample saturated in crude oil from a carbonate reservoir have shown avery good fit of the observed complex resistivity data by the GEMTIPmodel. Similar good fit was also observed upon comparing the observedand GEMTIP predicted data for other rock samples obtained from carbonatereservoirs.

In some implementations, the processing circuitry 152 can monitorchanges to the electrical resistivity and chargeability in thesubterranean zone 104, and correlate the changes to the electricalresistivity and chargeability to rock formations in the subterraneanzone. For example, the processing circuitry 152 can determine thatchanges to electrical resistivity and chargeability in portions of thesubterranean zone that carry higher quantities of hydrocarbons isdifferent from changes to electrical resistivity and chargeability inportions of the subterranean zone that have absorbed the IP fluid 125.To correlate the changes to the electrical resistivity and chargeabilityto rock formations in the subterranean zone, the processing circuitry152 can differentiate between the portions with different quantities ofhydrocarbons based on the differences between the changes to therespective electrical resistivities and chargeabilities. In this manner,the processing circuitry 152 can generate a volume image of electricresistivity and chargeability of the rock formations. Using thethree-dimensional inversion technique described, the processingcircuitry 152 can produce images with sharp contrast between portions ofthe subterranean zone 104 into which the IP fluid 125 has been absorbedand portions that carry more hydrocarbons into which lesser or noquantities of IP fluid 125 have been absorbed.

FIG. 2C shows an example of complex resistivity spectra determined for aportion of a subterranean zone. The portion of the subterranean zoneshown in FIG. 2C spans about 2.3 kilometers (km) by about 4.6 km. Someregions of the spectra (e.g., blue colored regions) are regions of lowinduced polarization while other regions of the spectra (e.g., redcolored regions, orange colored regions, yellow colored regions) areregions of comparatively high induced polarization. Green coloredregions in the spectra represent regions of intermediate inducedpolarization between the low induced polarization and the high inducedpolarization

FIG. 3 is a flowchart of an example of a process 300 for monitoring asubterranean zone using IP. In some implementations, the process 300 canbe implemented by the IP system 100. At 302, an injection fluid is dopedwith multiple particles resulting in IP fluid 125. For example, theinjection fluid can include brine. The particles can include inorganicnanoparticles, for example, ferrous nanoparticles.

At 304, the IP fluid is flowed into the subterranean zone. For example,the IP fluid 125 can be flowed into the subterranean zone 104 using thepumping system 106. As described above, some portions of thesubterranean zone (for example, portions in the same formation orportions in different formations) can carry more hydrocarbons than otherportions of the subterranean zone. The portions of the subterranean zonethat carry less hydrocarbons can absorb more quantities of the IP fluid125 than the portions that carry comparatively more hydrocarbons.

At 306, an electromagnetic signal is transmitted through thesubterranean zone. For example, the transmitter system is positioned inthe subterranean zone 104. The transmitter system transmits theelectromagnetic signal through the subterranean zone. Theelectromagnetic signal induces polarization in the IP fluid 125.

At 308, IP data is obtained. For example, the multiple receivers (forexample, receiver 110 a, 110 b, 110 c, 110 d, 110 e, or more or fewerreceivers), each of which is positioned on the surface 102, measure theIP data that is obtained responsive to the electromagnetic signal.

At 310, portions of the subterranean zone that carry lesser hydrocarbonsthan other portions are identified. For example, as described above, avolume distribution of electrical resistivity and chargeability in thesubterranean zone 104 is determined from the IP data. The volumedistribution of electrical resistivity and chargeability in thesubterranean zone 104 is determined by applying a 3D electromagneticinversion technique on the obtained IP data. The volume distribution forportions of the subterranean zone 104 that carry more hydrocarbons willbe different from the volume distribution for portions of thesubterranean zone 104 that carry correspondingly less hydrocarbons. Thedifferent in volume distribution of electrical resistivity andchargeability can be correlated to portions of the subterranean zone104. In this manner, portions of the subterranean zone 104 that carrymore hydrocarbons can be differentiated from portions that carrycomparatively lesser hydrocarbons.

Thus, particular implementations of the subject matter have beendescribed. Other implementations are within the scope of the followingclaims.

1-26. (canceled)
 27. A method comprising: inducing polarization in a subterranean zone using an induced polarization fluid, the subterranean zone comprising first formations and second formations, a quantity of hydrocarbons in the first formations greater than a quantity of hydrocarbons in the second formations; obtaining the induced polarization data from the subterranean zone, a portion of the induced polarization data from the first formations being different from a portion of the induced polarization data from the second formations; and identifying the second formations in the subterranean zone based on the obtained induced polarization data; monitoring changes to the electrical resistivity and chargeability in the subterranean zone, wherein changes to electrical resistivity and chargeability in the first formations are different from changes to electrical resistivity and chargeability in the second formations that have absorbed the induced polarization fluid; and correlating the changes to the electrical resistivity and chargeability to rock formations in the subterranean zone, wherein correlating comprises differentiating between first formations and second formations based on differences between the changes to the electrical resistivity and chargeability in the first formations and the changes to the electrical resistivity and chargeability in the second formations that have absorbed the induced polarization fluid.
 28. The method of claim 27, further comprising flowing the induced polarization fluid into the subterranean zone, wherein the second formations absorb more induced polarization fluid than the first formations.
 29. The method of claim 27, wherein the induced polarization fluid comprises an injection fluid comprising a plurality of particles configured to induce polarization in an electromagnetic field.
 30. The method of claim 29, wherein the plurality of particles comprises nanoparticles.
 31. The method of claim 29, wherein the injection fluid comprises organic material and the plurality of particles comprise inorganic material.
 32. The method of claim 29, wherein the injection fluid comprises brine.
 33. The method of claim 27, wherein the subterranean zone comprises an injection wellbore into which the induced polarization fluid is flowed.
 34. The method of claim 33, further comprising tracing flow of the induced polarization fluid through the injection wellbore based, in part, on the obtained induced polarization data.
 35. The method of claim 27, wherein the first formations comprise reservoir rock at least partially saturated with hydrocarbons.
 36. The method of claim 27, wherein identifying the second formations based on the obtained induced polarization data comprises determining volume distribution of electrical resistivity and chargeability in the subterranean zone from the induced polarization data.
 37. The method of claim 36, wherein determining the volume distribution of electrical resistivity and chargeability in the subterranean zone comprises applying a three-dimensional electromagnetic inversion technique on the obtained induced polarization data.
 38. The method of claim 27, wherein inducing polarization in the subterranean zone using the induced polarization fluid comprises applying a plurality of alternating currents at a plurality of different frequencies to the subterranean zone, wherein obtaining the induced polarization data from the subterranean zone comprises: measuring, for each alternating current at each of the plurality of different frequencies, a respective phase shift between voltage and current for the alternating current; and determining, for the plurality of different frequencies, a complex resistivity spectrum of the subterranean zone, the complex resistivity spectrum comprising a real resistivity part and an imaginary resistivity part.
 39. A system comprising: processing circuitry configured to perform operations comprising: obtaining induced polarization data from a subterranean zone, the subterranean zone comprising first formations and second formations, a quantity of hydrocarbons in the first formations greater than a quantity of hydrocarbons in the second formations, the induced polarization data induced in the subterranean zone using an induced polarization fluid, a portion of the induced polarization data from the first formations being different from a portion of the induced polarization data from the second formations; identifying the second formations in the subterranean zone based on the obtained induced polarization data; monitoring changes to the electrical resistivity and chargeability in the subterranean zone, wherein changes to electrical resistivity and chargeability in the first formations are different from changes to electrical resistivity and chargeability in the second formations that have absorbed the induced polarization; and correlating the changes to the electrical resistivity and chargeability to rock formations in the subterranean zone, wherein correlating comprises differentiating between first formations and second formations based on differences between the changes to the electrical resistivity and chargeability in the first formations and the changes to the electrical resistivity and chargeability in the second formations that have absorbed the induced polarization fluid.
 40. The system of claim 39, further comprising: a transmitter positioned within the subterranean zone, the transmitter configured to transmit a plurality of alternating currents at a plurality of different frequencies through the subterranean zone, wherein the induced polarization data is generated in the subterranean zone in response to the plurality of alternating currents at the plurality of different frequencies; and a plurality of receivers, each receiver positioned on a surface of the subterranean zone, each receiver configured to measure at least a portion of the induced polarization data generated in the subterranean zone in response to the plurality of alternating currents at a plurality of different frequencies, wherein the portion of the induced polarization data comprises, for each alternating current at a respective frequency, a respective complex resistivity spectrum of the subterranean zone.
 41. The system of claim 39, further comprising the induced polarization fluid, the induced polarization fluid comprising an injection fluid comprising a plurality of particles configured to induce polarization in an electromagnetic field.
 42. The system of claim 39, wherein the plurality of particles comprises nanoparticles.
 43. The system of claim 39, wherein the injection fluid comprises organic material and the plurality of particles comprise inorganic material.
 44. The system of claim 39, wherein the injection fluid comprises brine.
 45. The system of claim 39, wherein the subterranean zone comprises an injection wellbore into which the induced polarization fluid is flowed, and wherein the processing circuitry is further configured to trace flow of the induced polarization fluid through the injection wellbore based, in part, on the obtained induced polarization data.
 46. The system of claim 39, further comprising a pumping system configured to flow the induced polarization fluid into the subterranean zone.
 47. The system of claim 39, wherein, to identify the second formations based on the obtained induced polarization data, the processing circuitry is configured to determine volume distribution of electrical resistivity and chargeability in the subterranean zone from the induced polarization data.
 48. The system of claim 39, wherein to determine volume distribution of electrical resistivity and chargeability in the subterranean zone from the induced polarization data, the processing circuitry is configured to apply a three-dimensional electromagnetic inversion technique on the obtained induced polarization data. 